Evergy Kansas Central 10Q/A 2002 Q1 Quarterly report (amended)

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 10-Q/A

x QUARTERLY REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2002

OR

o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ________ to _________

Commission File Number 1-3523

Western Resources, Inc. (now named Westar Energy, Inc.)

(Exact name of registrant as specified in its charter)

Kansas		48-0290150

(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

818 South Kansas Avenue Topeka, Kansas 66612 (785) 575-6300

(Address, including Zip code and telephone number, including area code, of registrant’s principal executive offices)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes

Indicate the number of shares outstanding of each of the registrant’s classes of common stock, as of the latest practicable date.

Common Stock, par value $5.00 per share		71,729,989 Shares

(Class)		(Outstanding at May 8, 2002)

INTRODUCTORY NOTE

The registrant is filing this Form 10-Q/A to give effect to the restatements as discussed in Note 15 of the “Notes to Consolidated Financial Statements.”

As announced in our press release of November 7, 2002, our board of directors has placed David C. Wittig, our Chairman of the Board, President and Chief Executive Officer, on administrative leave without pay from all of his positions with us or any of our affiliates following his indictment by a federal grand jury in Topeka, Kansas for actions arising from his personal dealings with the former president of a Topeka, Kansas bank. We also announced that our board of directors intends to appoint an acting President and Chief Executive Officer promptly. Currently, a committee appointed by our board of directors comprised of our senior executive officers is performing functions similar and equivalent to those performed by a principal executive officer or chief executive officer. As a result, the principal and chief executive officer certifications required by Rule 13a-14 under the Securities Exchange Act of 1934 and Section 906 of the Sarbanes-Oxley Act of 2002 which accompany this Form 10-Q are signed by the members of such committee.

TABLE OF CONTENTS

		Page

PART I. Financial Information

Item 1.	Financial Statements

	Consolidated Balance Sheets	5

	Consolidated Statements of Income (Loss)	6

	Consolidated Statements of Comprehensive Income (Loss)	7

	Consolidated Statements of Cash Flows	8

	Notes to Consolidated Financial Statements	9

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	22

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	37

PART II. Other Information

Item 1.	Legal Proceedings	38

Item 2.	Changes in Securities and Use of Proceeds	39

Item 3.	Defaults Upon Senior Securities	39

Item 4.	Submission of Matters to a Vote of Security Holders	39

Item 5.	Other Information	39

Item 6.	Exhibits and Reports on Form 8-K	39

Signature		40

Certifications		41

FORWARD-LOOKING STATEMENTS

Certain matters discussed in this Form 10-Q/A are “forward-looking statements.” The Private Securities Litigation Reform Act of 1995 has established that these statements qualify for safe harbors from liability. Forward-looking statements may include words like we “believe,” “anticipate,” “expect,” or words of similar meaning. Forward-looking statements describe our future plans, objectives, expectations or goals. Such statements address future events and conditions concerning:

	•	capital expenditures,
	•	earnings,
	•	liquidity and capital resources,
	•	litigation,
	•	possible corporate restructurings, mergers, acquisitions and dispositions,
	•	compliance with debt and other restrictive covenants,
	•	interest and dividends,
	•	Protection One, Inc.’s financial condition and its impact on our consolidated results,
	•	impairment charges recorded during the first quarter of 2002,
	•	environmental matters,
	•	nuclear operations,
	•	ability to enter new markets successfully and capitalize on growth opportunities in non-regulated businesses,
	•	events in foreign markets in which investments have been made and
	•	the overall economy of our service area.

	What happens in each case could vary materially from what we expect because of such things as:
	•	electric utility deregulation,
	•	ongoing municipal, state and federal activities, such as the Wichita municipalization effort,
	•	future economic conditions,
	•	changes in accounting requirements and other accounting matters,
	•	changing weather,
	•	rate and other regulatory matters, including the impact of (i) the Kansas Corporation Commission’s order to reduce our rates issued on July 25, 2001, (ii) the Kansas Corporation Commission’s order issued July 20, 2001 and related proceedings, with respect to the proposed separation of Western Resources, Inc.’s electric utility businesses from Westar Industries, Inc., and (iii) the Kansas Corporation Commission’s recent comments and orders relating to our Federal Energy Regulatory Commission financing authority,
	•	the impact on our service territory of the September 11, 2001 terrorist attacks,
	•	the impact of Enron Corp.’s bankruptcy on the market for trading wholesale electricity,
	•	political, legislative and regulatory developments,
	•	amendments or revisions to our current business and financial plans,
	•	the consummation of the acquisition of the electric operations of Western Resources, Inc. by Public Service Company of New Mexico and related litigation,
	•	regulatory, legislative and judicial actions,
	•	regulated and competitive markets,
	•	changes in the 10-year United States Treasury rates and the corresponding impact on the fair value of our call option contract and
	•	other circumstances affecting anticipated operations, sales and costs.

These lists are not all-inclusive because it is not possible to predict all possible factors.

See “Item 1. Business — Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2001, for additional information on matters that could impact our expectations. Any forward-looking statement speaks only as of the date such statement was made, and we do not undertake any obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement was made.

RESTATEMENTS

We have restated our consolidated financial statements as of March 31, 2002 and for the period then ended. We are correcting amounts related to the extraordinary gain recognized on the retirement of our debt to include the fair value of the call option associated with our 6.25% senior unsecured notes at the time the notes were retired. Also, the change in the fair value of the call option subsequent to the retirement of the notes has been recognized in other income in the accompanying restated consolidated financial statements.

In addition, we are reporting our share of an additional impairment charge at Protection One, Inc., pursuant to Statement of Financial Accounting Standards (SFAS) No. 142, “Accounting for Goodwill and Other Intangible Assets,” and SFAS No. 144, “Accounting for the Impairment and Disposal of Long-Lived Assets.” We have included an additional impairment charge for goodwill in the cumulative effect of a change in accounting principle amount previously reported by Protection One and the additional impairment charge for customer accounts in the operating expense previously reported.

See Note 15 of the Notes to the Consolidated Financial Statements, “Restatements of Our Consolidated Financial Statements,” for detailed information concerning the restatements. We have amended and restated in its entirety the Form 10-Q for the three months ended March 31, 2002, filed on May 15, 2002, to reflect the restatements. In order to preserve the nature and the character of the disclosures as of May 15, 2002, no attempt has been made in this Form 10-Q/A to modify or update such disclosures except as required to reflect the results of the restatements.

WESTERN RESOURCES, INC.
CONSOLIDATED BALANCE SHEETS
(Dollars in Thousands)
(Unaudited)

			March 31, 2002			December 31, 2001

			(As Restated, See Note 15)

ASSETS
CURRENT ASSETS:
	Cash and cash equivalents		$	93,620		$	96,691
	Restricted cash			19,627			14,795
	Accounts receivable, net			102,209			112,864
	Inventories and supplies, net			147,610			145,099
	Energy trading contracts			110,507			71,421
	Deferred tax assets			8,305			27,817
	Prepaid expenses and other			28,844			41,331

		Total Current Assets		510,722			510,018

PROPERTY, PLANT AND EQUIPMENT, NET				4,027,029			4,042,852

OTHER ASSETS:
	Restricted cash			35,072			38,515
	Investment in ONEOK			603,551			598,929
	Customer accounts, net			473,719			830,708
	Goodwill, net			188,388			884,786
	Regulatory assets			354,511			358,025
	Energy trading contracts			19,929			15,247
	Other			254,724			233,985

		Total Other Assets		1,929,894			2,960,195

TOTAL ASSETS			$	6,467,645		$	7,513,065

LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
	Current maturities of long-term debt		$	661,482		$	160,576
	Short-term debt			397,700			222,300
	Accounts payable			123,830			125,285
	Accrued liabilities			175,931			181,671
	Accrued income taxes			23,852			39,770
	Deferred security revenues			47,201			48,461
	Energy trading contracts			94,416			67,859
	Other			56,558			57,459

		Total Current Liabilities		1,580,970			903,381

LONG-TERM LIABILITIES:
	Long-term debt, net			2,301,186			2,978,382
	Western Resources obligated mandatorily redeemable preferred securities of subsidiary trusts holding solely company subordinated debentures			219,668			220,000
	Deferred income taxes and investment tax credits			732,383			924,178
	Minority interests			69,150			166,850
	Deferred gain from sale-leaseback			171,509			174,466
	Energy trading contracts			13,470			16,500
	Other			284,976			285,247

		Total Long-Term Liabilities		3,792,342			4,765,623

COMMITMENTS AND CONTINGENCIES

SHAREHOLDERS’ EQUITY:
	Cumulative preferred stock, par value $100 per share; authorized 600,000 shares; issued 248,576 shares; outstanding 219,385 shares and 239,364 shares, respectively			21,939			23,936
	Common stock, par value $5 per share; authorized 150,000,000 shares; issued 86,923,632 shares and 86,205,417 shares, respectively			434,618			431,027
	Paid-in capital			1,203,329			1,196,763
	Unearned compensation			(20,865	)		(21,920	)
	Loans to officers			(2,095	)		(1,973	)
	Retained earnings (accumulated deficit)			(161,210	)		606,502
	Treasury stock, at cost, 15,494,755 and 15,097,987 shares, respectively			(371,535	)		(364,901	)
	Accumulated other comprehensive loss, net			(9,848	)		(25,373	)

		Total Shareholders’ Equity		1,094,333			1,844,061

TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY			$	6,467,645		$	7,513,065

The accompanying notes are an integral part of these consolidated financial statements.

WESTERN RESOURCES, INC.

CONSOLIDATED STATEMENTS OF INCOME (LOSS)
(Dollars in Thousands, Except Per Share Amounts)
(Unaudited)

			Three Months Ended March 31,

			2002			2001

			(As Restated, See Note 15)

SALES:
	Energy		$	412,281		$	446,018
	Monitored Services			89,960			114,723

		Total Sales		502,241			560,741

COST OF SALES:
	Energy			183,738			228,780
	Monitored Services			29,685			40,824

		Total Cost of Sales		213,423			269,604

GROSS PROFIT				288,818			291,137

OPERATING EXPENSES:
	Operating and maintenance			93,389			92,683
	Depreciation and amortization			74,587			102,486
	Selling, general and administrative			99,123			78,874
	Loss on impairment of customer accounts			339,974			¾

		Total Operating Expenses		607,073			274,043

INCOME (LOSS) FROM OPERATIONS				(318,255	)		17,094

OTHER INCOME (EXPENSE):
	Investment earnings			32,708			13,265
	Minority interests			96,569			1,271
	Other			(3,186	)		(3,155	)

		Total Other Income		126,091			11,381

EARNINGS (LOSSES) BEFORE INTEREST AND TAXES				(192,164	)		28,475

INTEREST EXPENSE:
	Interest expense on long-term debt			50,458			55,745
	Interest expense on short-term debt and other			11,425			10,956

		Total Interest Expense		61,883			66,701

LOSSES BEFORE INCOME TAXES				(254,047	)		(38,226	)
Income tax benefit				(127,290	)		(19,039	)

NET LOSS BEFORE EXTRAORDINARY GAIN AND ACCOUNTING CHANGE				(126,757	)		(19,187	)
Extraordinary gain, net of tax of $2,062 and $2,662, respectively				3,948			4,943
Cumulative effect of accounting change, net of tax of $72,335 and $12,347, respectively				(623,717	)		18,694

NET INCOME (LOSS)				(746,526	)		4,450

PREFERRED STOCK:
	Gain on reacquired preferred stock			465			¾
	Preferred dividends			(249	)		(282	)

		Total change in preferred stock		216			(282	)

EARNINGS (LOSSES) AVAILABLE FOR COMMON STOCK			$	(746,310	)	$	4,168

Average common shares outstanding				71,368,922			70,359,298

BASIC AND DILUTED EARNINGS PER AVERAGE COMMON SHARE OUTSTANDING:
	Basic and diluted earnings (losses) available before extraordinary gain and accounting change		$	(1.77	)	$	(0.28	)
	Extraordinary gain, net of tax			0.05			0.07
	Accounting change, net of tax			(8.74	)		0.27

	Basic and diluted earnings (losses) available after extraordinary gain and accounting change		$	(10.46	)	$	0.06

DIVIDENDS DECLARED PER COMMON SHARE			$	0.30		$	0.30

The accompanying notes are an integral part of these consolidated financial statements.

WESTERN RESOURCES, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in Thousands)
(Unaudited)

			Three Months Ended March 31,

			2002					2001

			(As Restated, See Note 15)

NET INCOME (LOSS)					$	(746,526	)				$	4,450

OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX:
	Unrealized holding losses on marketable securities arising during the period		$	¾				$	(243	)
	Adjustment for losses included in net income			¾		¾			1,861			1,618

	Unrealized holding gains on cash flow hedges arising during the period			22,205					¾
	Adjustment for losses included in net income			964		23,169			¾			¾

	Foreign currency translation adjustment					445						(2,745	)
	Income tax expense					(8,089	)					(693	)

		Total other comprehensive gain (loss), net of tax				15,525						(1,820	)

COMPREHENSIVE INCOME (LOSS)					$	(731,001	)				$	2,630

The accompanying notes are an integral part of these consolidated financial statements.

WESTERN RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in Thousands)
(Unaudited)

				Three Months Ended March 31,

				2002			2001

				(As Restated, See Note 15)

CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
	Net income (loss)			$	(746,526	)	$	4,450
	Adjustments to reconcile net income (loss) to net cash provided by operating activities:
	Extraordinary gain				(3,948	)		(4,943	)
	Cumulative effect of accounting change				623,717			(18,694	)
	Depreciation and amortization				74,587			102,486
	Amortization of deferred gain from sale-leaseback				(2,957	)		(2,957	)
	Net changes in energy trading assets and liabilities				(244	)		(5,379	)
	Net changes in fair value of call option				(1,415	)		—
	Equity in earnings from investments				(4,529	)		(4,157	)
	Loss on impairment of customer accounts				339,974			—
	Minority interests				(96,569	)		1,271
	Accretion of discount note interest				(120	)		(352	)
	Net deferred taxes				(110,406	)		(904	)
	Changes in working capital items, net of acquisitions and dispositions:
		Restricted cash			(4,833	)		1,228
		Accounts receivable, net			(261	)		60,825
		Inventories and supplies, net			(2,511	)		(6,034	)
		Prepaid expenses and other			11,619			7,685
		Accounts payable			(1,455	)		(36,553	)
		Accrued liabilities			(5,740	)		(18,601	)
		Accrued income taxes			(15,918	)		(20,869	)
		Deferred security revenues			(1,260	)		4,087
	Changes in other assets and liabilities				(33,857	)		(3,741	)

			Cash flows from operating activities		17,348			58,848

CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
	Additions to property, plant and equipment, net				(32,004	)		(63,130	)
	Customer account acquisitions				(8,477	)		(8,906	)
	Proceeds from other investments				28,283			2,008

			Cash flows used in investing activities		(12,198	)		(70,028	)

CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
	Short-term debt, net				175,400			42,530
	Proceeds of long-term debt				8,420			8,632
	Retirements of long-term debt				(171,630	)		(19,067	)
	Retirement of Western Resources obligated mandatorily redeemable preferred securities of subsidiary trusts holding solely company subordinated debentures				(257	)		—
	Issuance of officer loans				(100	)		—
	Issuance of common stock, net				4,849			9,902
	Cash dividends paid				(21,530	)		(25,401	)
	Preferred stock redemption				(1,253	)		—
	Acquisition of treasury stock				(2,120	)		—

			Cash flows from (used in) financing activities		(8,221	)		16,596

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS					(3,071	)		5,416
CASH AND CASH EQUIVALENTS:
	Beginning of period				96,691			8,762

	End of period			$	93,620		$	14,178

SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
	CASH PAID FOR:
	Interest on financing activities, net of amount capitalized			$	89,015		$	92,782
	Income taxes			$	—		$	4,000

The accompanying notes are an integral part of these consolidated financial statements.

WESTERN RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2002
(Unaudited)

1. DESCRIPTION OF BUSINESS

Western Resources, Inc. (now named Westar Energy, Inc.) is a publicly traded consumer services company incorporated in 1924 in the State of Kansas. Unless the context otherwise indicates, all references on this Form 10-Q/A to “the company,” “Western Resources,” “we,” “us,” “our” or similar words are to Western Resources, Inc., and its consolidated subsidiaries. We provide electric generation, transmission and distribution services to approximately 644,000 customers in Kansas and monitored security services to more than 1.2 million customers in North America and Europe. ONEOK, Inc. (ONEOK), in which we have an approximate 45% ownership interest, provides natural gas transmission and distribution services to approximately 1.4 million customers in Oklahoma and Kansas.

We and Kansas Gas and Electric Company (KGE), a wholly owned subsidiary, provide rate-regulated electric service using the name Westar Energy. KGE owns 47% of Wolf Creek Nuclear Operating Corporation (WCNOC), the operating company for Wolf Creek Generating Station (Wolf Creek).

Westar Industries, Inc. (Westar Industries), our wholly owned subsidiary, owns our interests in Protection One, Inc. (Protection One), Protection One Europe, ONEOK and other non-utility businesses. Protection One, a publicly traded, approximately 88%-owned subsidiary, and Protection One Europe provide monitored security services. Protection One Europe refers collectively to Protection One International, Inc., a wholly owned subsidiary of Westar Industries, and its subsidiaries, including a French subsidiary in which it owns approximately a 99.8% interest.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

We prepare our consolidated financial statements in accordance with accounting principles generally accepted in the United States (GAAP) for interim financial information and in accordance with the instructions to Form 10-Q. Accordingly, certain information and footnote disclosures normally included in financial statements presented in accordance with GAAP have been condensed or omitted. The accompanying consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and the notes included in our Annual Report on Form 10-K for the year ended December 31, 2001.

Use of Management’s Estimates

The preparation of consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of our consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. In management’s opinion, all adjustments, consisting only of normal recurring adjustments considered necessary for a fair presentation of the financial statements, have been included. The results of operations for the three months ended March 31, 2002, are not necessarily indicative of the results to be expected for the full year.

Cumulative Effects of Accounting Changes

Effective January 1, 2002, we adopted Statement of Financial Accounting Standards (SFAS) No. 142, “Accounting for Goodwill and Other Intangible Assets.” See Note 3, “Impairment Charge Pursuant to New Accounting Rules,” below for the cumulative effect of this adoption.

Effective January 1, 2001, we adopted SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities,” as amended by SFAS Nos. 137 and 138 (collectively, SFAS No. 133). We use derivative instruments (primarily swaps, options and futures) to manage interest rate exposure and the commodity price risk inherent in fossil fuel purchases and electricity sales. Under SFAS No. 133, all derivative instruments, including our energy trading contracts, are recorded on our consolidated balance sheet as either an asset or liability measured at fair value. Changes in a derivative’s fair value must be recognized currently in earnings unless specific hedge accounting criteria are met. Cash flows from derivative instruments are presented in net cash flows from operating activities.

Derivative instruments used to manage commodity price risk inherent in fuel purchases and electricity sales are classified as energy trading contracts on our consolidated balance sheet. Energy trading contracts representing unrealized gain positions are reported as assets; energy trading contracts representing unrealized loss positions are reported as liabilities.

Prior to January 1, 2001, gains and losses on our derivatives used for managing commodity price risk were deferred until settlement. These derivatives were not designated as hedges under SFAS No. 133. Accordingly, on January 1, 2001, we recognized an unrealized gain of $18.7 million, net of $12.3 million of tax. This gain is presented on our consolidated statement of income in our Annual Report on Form 10-K for the year ended December 31, 2001 as a cumulative effect of a change in accounting principle.

After January 1, 2001, changes in fair value of all derivative instruments used for managing commodity price risk that are not designated as hedges are recognized in revenue as discussed in Note 2 of the “Notes to Consolidated Financial Statements” in our Annual Report on Form 10-K for the year ended December 31, 2001. Accounting for derivatives under SFAS No. 133 will increase volatility of our future earnings.

Reclassifications

Certain amounts in prior years have been reclassified to conform with classifications used in the current year presentation.

3. IMPAIRMENT CHARGE PURSUANT TO NEW ACCOUNTING RULES

Effective January 1, 2002, we adopted the new accounting standards SFAS No. 142, “Accounting for Goodwill and Other Intangible Assets,” and SFAS No. 144, “Accounting for the Impairment and Disposal of Long-Lived Assets.” SFAS No. 142 establishes new standards for accounting for goodwill. SFAS No. 142 continues to require the recognition of goodwill as an asset, but discontinues amortization of goodwill. In addition, annual impairment tests must be performed using a fair-value based approach as opposed to an undiscounted cash flow approach required under prior standards.

SFAS No. 144 establishes a new approach to determining whether our customer account asset is impaired. The approach no longer permits us to evaluate our customer account asset for impairment based on the net undiscounted cash flow stream obtained over the remaining life of the goodwill associated with the customer accounts being evaluated. Rather, the cash flow stream to be used under SFAS No. 144 is limited to future estimated undiscounted cash flows from customer accounts. If the undiscounted cash flow stream from customer accounts is less than the combined book value of customer accounts and goodwill, an impairment charge would be required.

The new rule substantially reduces the net undiscounted cash flows used for impairment evaluation purposes as compared to the previous accounting rules. The undiscounted cash flow stream has been reduced from the 16-year remaining life of the goodwill to the remaining life of customer accounts for impairment evaluation purposes.

To implement the new standards, an independent appraisal firm was engaged to help management estimate the fair values of goodwill and customer accounts. Based on this analysis completed during the first quarter of 2002, we recorded a non-cash charge of approximately $749.5 million, net of tax, of which $555.6 million is related to goodwill and $193.9 million is related to customer accounts. The charge is detailed as follows:

		Impairment of Goodwill		Impairment of Customer Accounts		Total

				(In Thousands)

Protection One		$	615,948	$	339,974	$	955,922
Protection One Europe			80,104		—		80,104

	Total pre-tax impairment	$	696,052	$	339,974		1,036,026

Income tax benefit							(190,676	)
Minority interest ownership							(95,886	)

	Total charge, net of tax					$	749,464

The impairment charge for goodwill is reflected in our consolidated statement of income as a cumulative effect of a change in accounting principle. The impairment charge for customer accounts is reflected in our consolidated statement of income as an operating expense. These impairment charges reduce the recorded value of these assets to their estimated fair values at January 1, 2002. See Note 15 for information concerning the restatements to report an additional impairment charge for our share of the impairment charge for goodwill and customer accounts recorded by Protection One.

We are no longer permitted to amortize goodwill to income because of the adoption of SFAS No. 142. The following table shows our results for the three months ended March 31, 2001, calculated using the new accounting standard for goodwill, adjusted for minority interest, compared to our results for the same period of 2002.

		Three Months Ended March 31,

		2002			2001

		(In Thousands, Except Per Share Amounts)

	Reported earnings (losses) available for common stock	$	(746,310	)	$	4,168
	Add back: Goodwill amortization		—			14,418

	Adjusted earnings (losses) available for common stock	$	(746,310	)	$	18,586

Basic and diluted earnings per share:
	Reported earnings (losses) available for common stock	$	(10.46	)	$	0.06
	Add back: Goodwill amortization		—			0.20

	Adjusted earnings (losses) available for common stock	$	(10.46	)	$	0.26

We recorded approximately $22.4 million of customer account amortization expense during the three months ended March 31, 2002 and $38.7 million during the same period of 2001. Customer account amortization expense is reduced primarily as a result of the impairment charge that reduced our customer account balance.

We will be required to perform impairment tests for long-lived assets prospectively for our monitored services segment as long as it continues to incur recurring losses or for other matters that may negatively impact its businesses. Goodwill will be required to be tested each year for impairment. Declines in market values of our monitored services businesses or the value of customer accounts that may be incurred prospectively may require additional impairment charges in the future, which could be material.

4. CHANGE IN ESTIMATE OF CUSTOMER LIFE

During the first quarter of 2002, Protection One evaluated the estimated life and amortization rates for customer accounts, given the results of a lifing study performed by a third party appraisal firm in the first quarter of 2002. The lifing study showed a deterioration in the average remaining life of customer accounts. Protection One’s management determined it was appropriate, given the results of the lifing study, to adjust the rate of amortization on customer accounts for its North America and Multifamily customer pools. In the first quarter of 2002, Protection

One changed its amortization rate for its North America pool to a 10-year 135% declining balance method from a 10-year 130% declining balance method. For the Multifamily pool, Protection One reduced its estimated customer life from 10 to 9 years and will continue to amortize on a straight-line basis. We account for these amortization changes prospectively as a change in estimate. These changes in estimates increased amortization expense for the three months ended March 31, 2002 on a pre-tax basis by approximately $0.3 million.

5. RATE MATTERS AND REGULATION

KCC Rate Proceedings

On November 27, 2000, we and KGE filed applications with the Kansas Corporation Commission (KCC) for an increase in retail rates. On July 25, 2001, the KCC ordered an annual reduction in our combined electric rates of $22.7 million, consisting of a $41.2 million reduction in KGE’s rates and an $18.5 million increase in our rates.

On August 9, 2001, we and KGE filed petitions with the KCC requesting reconsideration of the July 25, 2001 order. The petitions specifically asked for reconsideration of changes in depreciation, reductions in rate base related to deferred income taxes associated with the KGE acquisition premium and a deferred gain on the sale and leaseback of our LaCygne 2 generating unit, wholesale revenue imputation and several other issues. On September 5, 2001, the KCC issued an order in response to our motions for reconsideration that increased our rates by an additional $7.0 million. The $41.2 million rate reduction in KGE’s rates remained unchanged. This resulted in the total company rate decrease of $15.7 million. On November 9, 2001, we filed an appeal of the KCC decisions with the Kansas Court of Appeals in an action captioned “Western Resources, Inc. and Kansas Gas and Electric Company vs. The State Corporation Commission of the State of Kansas.” On March 8, 2002, the Court of Appeals upheld the KCC orders. On April 8, 2002, we filed a petition for review of the decision of the Court of Appeals with the Kansas Supreme Court, which has discretion to decide whether to hear this matter. We petitioned the court to review the KCC’s rulings related to deferred income taxes associated with the KGE acquisition premium and a deferred gain on the sale and leaseback of our LaCygne 2 generating unit. We can give no assurance that the Kansas Supreme Court will accept our petition for review and there is no time limit for action by the Kansas Supreme Court.

KCC Investigation and Order

See Note 6 for a discussion of the order issued by the KCC on July 20, 2001 in the KCC’s docket investigating the proposed separation of our electric utility businesses from our non-utility businesses and other aspects of our unregulated businesses.

FERC Proceeding

Our wholly owned subsidiary, Westar Generating, Inc. (Westar Generating), owns our interest in the State Line generating facility. We purchase Westar Generating’s share of the power generated by State Line. The Federal Energy Regulatory Commission (FERC) has jurisdiction over the establishment of the rate at which we buy power from Westar Generating. We have reached a settlement in principle with the FERC staff and the KCC, the only active parties in this proceeding. We expect to file a Stipulation and Agreement in the near future.

6. SPLIT-OFF OF WESTAR INDUSTRIES

KCC Proceedings and Orders

The merger with Public Service Company of New Mexico (PNM) contemplated the completion of a rights offering for shares of Westar Industries prior to closing. On May 8, 2001, the KCC opened an investigation of the proposed separation of our electric utility businesses from our non-utility businesses, including the rights offering, and other aspects of our unregulated businesses. The order opening the investigation indicated that the investigation would focus on whether the separation and other transactions involving our unregulated businesses are consistent with our obligation to provide efficient and sufficient electric service at just and reasonable rates to our electric utility customers. The KCC staff was directed to investigate, among other matters, the basis for and the effect of the Asset Allocation and Separation Agreement we entered into with Westar Industries in connection with the proposed

separation and the intercompany payable owed by us to Westar Industries, the separation of Westar Industries, the effect of the business difficulties faced by our unregulated businesses and whether they should continue to be affiliated with our electric utility business, and our present and prospective capital structures. On May 22, 2001, the KCC issued an order nullifying the Asset Allocation and Separation Agreement, prohibiting Westar Industries and us from taking any action to complete the rights offering for common stock of Westar Industries, which was to be a first step in the separation, and scheduling a hearing to consider whether to make the order permanent.

On July 20, 2001, the KCC issued an order that, among other things: (1) confirmed its May 22, 2001 order prohibiting us and Westar Industries from taking any action to complete the proposed rights offering and nullifying the Asset Allocation and Separation Agreement; (2) directed us and Westar Industries not to take any action or enter into any agreement not related to normal utility operations that would directly or indirectly increase the share of debt in our capital structure applicable to our electric utility operations, which has the effect of prohibiting us from borrowing to make a loan or capital contribution to Westar Industries; and (3) directed us to present a financial plan consistent with parameters established by the KCC’s order to restore financial health, achieve a balanced capital structure and protect ratepayers from the risks of our non-utility businesses. In its order, the KCC also acknowledged that we are currently operating efficiently and at reasonable cost and stated that it was not disapproving the PNM transaction or a split-off of Westar Industries. We appealed the orders issued by the KCC to the District Court of Shawnee County, Kansas. On February 5, 2002, the District Court issued a decision finding that the KCC orders were not final orders and that the District Court lacked jurisdiction to consider the appeal. Accordingly, the matter was remanded to the KCC for review of the financial plan.

On February 11, 2002, the KCC issued an order primarily related to procedural matters for the review of the financial plan, as discussed below. In addition, the order required that we and the KCC staff make filings addressing whether the filing of applications by us and KGE at FERC, seeking renewal of existing borrowing authority, violated the July 20, 2001 KCC order directing that we not increase the share of debt in our capital structure applicable to our electric utility operations. The KCC staff subsequently filed comments asserting that the refinancing of existing indebtedness with new indebtedness secured by utility assets would in certain circumstances violate the July 20, 2001 KCC order. The KCC filed a motion to intervene in the proceeding at FERC asserting the same position.

On March 26, 2002, the KCC issued an order in which it acknowledged that our FERC filings technically did not violate the July 20, 2001 KCC order. However, the KCC expressed concern that our refinancing plans as described in the FERC filings could, when implemented, increase the share of debt in the capital structure applicable to our electric utility operations. By agreement with the KCC staff and other intervenors, the FERC applications have been amended so that the requested authority is limited to short-term (12 months or less) borrowing authority and, as a result, the KCC’s and certain other parties’ interventions were withdrawn. We intend to file applications for authority for medium-term financing with the FERC and are unable to predict the extent to which the FERC will incorporate the KCC staff position in orders renewing that borrowing authority, or any resulting impact on our ability to refinance indebtedness maturing in the next several years. However, an inability to refinance existing indebtedness on a secured basis would likely increase our borrowing costs, and any other limitations on our ability to refinance existing debt would adversely affect our results of operations.

The Financial Plan

The July 20, 2001 KCC order directed us to present a financial plan to the KCC. We presented a financial plan to the KCC on November 6, 2001, which we amended on January 29, 2002. Our financial plan is set forth in full in our Annual Report on Form 10-K for the year ended December 31, 2001 under “Item 1. Business — Significant Business Developments — The Financial Plan.” The principal objective of the financial plan is to reduce our total debt as calculated by the KCC to approximately $1.8 billion, a reduction of approximately $1.2 billion. The financial plan contemplates that we will proceed with a rights and warrants offering of Westar Industries common stock to our shareholders and that, in the event that the PNM merger and related split-off do not close, we will use our best efforts to sell our share of Westar Industries common stock, or shares of our common stock, upon the occurrence of certain events. The KCC has scheduled a hearing to begin on July 1, 2002 to review the financial plan. We are unable to predict whether the KCC will approve the financial plan or what other action with respect to the financial plan the KCC may take.

7. INCOME TAXES

We have recorded income tax benefits for the interim periods using the effective tax rate method. Under this method, we compute the tax related to year-to-date income, except for significant, unusual or extraordinary items, at an estimated annual effective tax rate. We individually compute and recognize, when the transaction occurs, income tax expense related to significant, unusual or extraordinary items. Our effective income tax benefit was 50% for both the three months ended March 31, 2002 and 2001.

The difference between our effective tax rate and the statutory rate is primarily attributable to the impairment charge recorded in the first quarter of 2002 and the tax benefit of excluding from taxable income, in accordance with IRS rules, 70% of the dividends received from ONEOK, the income from corporate-owned life insurance and certain expenses for depreciation, amortization and state income taxes. For further information regarding the impairment charge, see Note 3, “Impairment Charge Pursuant to New Accounting Rules.”

8. WORK FORCE REDUCTIONS

In the first quarter of 2002, we and Protection One reduced our work forces by approximately 600 employees through a voluntary separation program and facility consolidations. We and Protection One recorded a severance charge of approximately $21.9 million, net of tax, in the first quarter of 2002. We may replace some of these employees.

9. ICE STORM

In late January 2002, a severe ice storm swept through our utility service area causing extensive damage and loss of power to numerous customers. Through March 31, 2002, we incurred total costs of $16.1 million for restoration costs, a portion of which was capitalized. We have deferred and recorded in other assets on our March 31, 2002 consolidated balance sheet operating costs of approximately $13.1 million. We have received an accounting authority order from the KCC that allows us to accumulate and defer for future recovery all operating costs related to storm restoration. We currently estimate total restoration costs at approximately $18 million, rather than our previously reported estimate of $25 million.

10. EXTRAORDINARY GAIN ON SECURITIES

Protection One and our debt securities were repurchased in the open market and extraordinary gains were recognized on the retirement of these debt securities. The extraordinary gain recognized was $3.9 million, net of tax of $2.1 million, during the three months ended March 31, 2002, and $4.9 million, net of tax of $2.7 million, for the same period of 2001. In determining the extraordinary gain reported for the three months ended March 31, 2002, we recognized losses related to the fair value of a call option associated with our 6.25% senior unsecured notes at the time the notes were retired.

In April 2002, the Financial Accounting Standards Board (FASB) issued SFAS No. 145, “Rescission of FASB Statements No. 4, 44, and 64, Amendment of FASB Statement No. 13, and Technical Corrections.” This standard limits the income statement classification of gains and losses from extinguishment of debt as extraordinary to those transactions meeting the criteria of Accounting Principles Board (APB) Opinion No. 30, “Reporting the Results of Operations — Reporting the Effects of Disposal of a Segment of a Business, and Extraordinary, Unusual and Infrequently Occurring Events and Transactions.” SFAS No. 145 prohibits treating gains and losses associated with extinguishments resulting from a company’s risk management strategy as extraordinary. This standard is effective for fiscal years beginning after May 15, 2002 with early adoption encouraged. Gains or losses in prior periods that were classified as extraordinary that do not meet the APB Opinion No. 30 criteria will be required to be reclassified. We do not anticipate this pronouncement to have an impact on our earnings or financial condition.

11. LEGAL PROCEEDINGS

We, Westar Industries, Protection One, its subsidiary Protection One Alarm Monitoring, Inc. (Protection One Alarm Monitoring) and certain present and former officers and directors of Protection One are defendants in a purported class action litigation pending in the United States District Court for the Central District of California, “Alec Garbini, et al. v. Protection One, Inc., et al.,” No. CV 99-3755 DT (RCx). Pursuant to an Order dated August 2, 1999, four pending purported class actions were consolidated into a single action. On February 27, 2001, plaintiffs filed a Third Consolidated Amended Class Action Complaint (Third Amended Complaint). Plaintiffs purported to bring the action on behalf of a class consisting of all purchasers of publicly traded securities of Protection One, including common stock and bonds, during the period of February 10, 1998 through February 2, 2001. The Third Amended Complaint asserted claims under Section 11 of the Securities Act of 1933 and Section 10(b) of the Securities Exchange Act of 1934 against Protection One, Protection One Alarm Monitoring, and certain present and former officers and directors of Protection One based on allegations that various statements concerning Protection One’s financial results and operations for 1997, 1998, 1999 and the first three quarters of 2000 were false and misleading and not in compliance with generally accepted accounting principles. Plaintiffs alleged, among other things, that former employees of Protection One have reported that Protection One lacked adequate internal accounting controls and that certain accounting information was unsupported or manipulated by management in order to avoid disclosure of accurate information. The Third Amended Complaint further asserted claims against us and Westar Industries as controlling persons under Sections 11 and 15 of the Securities Act of 1933 and Sections 10(b) and 20(a) of the Securities Exchange Act of 1934. A claim was also asserted under Section 11 of the Securities Act of 1933 against Protection One’s auditor, Arthur Andersen LLP. The Third Amended Complaint sought an unspecified amount of compensatory damages and an award of fees and expenses, including attorneys’ fees. On June 4, 2001, the District Court (the Court) dismissed plaintiffs’ claims under Sections 10(b) and 20(a) of the Securities Exchange Act. The Court granted plaintiffs leave to replead such claims. The Court also dismissed all claims brought on behalf of bondholders with prejudice. The Court also dismissed plaintiffs’ claims against Arthur Andersen LLP and the plaintiffs have appealed that dismissal. On February 22, 2002, plaintiffs filed a Fourth Consolidated Amended Class Action Complaint. The new complaint realleges claims on behalf of purchasers of common stock under Sections 11 and 15 of the Securities Act of 1933 and Sections 10(b) and 20(a) of the Securities Exchange Act of 1934. The new complaint does not assert any claims against Protection One Alarm Monitoring. On April 5, 2002, we, Protection One and the other defendants filed a motion to dismiss the Fourth Consolidated Amended Class Action Complaint. The motion is scheduled to be heard by the Court on June 10, 2002. Protection One and we cannot predict the impact of this litigation, which could be material.

On October 12, 2001, PNM filed a lawsuit against us in the Supreme Court of the State of New York. The lawsuit seeks, among other things, declaratory judgment that PNM is not obligated to proceed with the proposed merger based in part upon the KCC orders discussed above and other KCC orders reducing rates for our electric utility business. PNM believes the orders constitute a material adverse effect and make the condition that the split-off of Westar Industries occur prior to closing incapable of satisfaction. PNM also seeks unspecified monetary damages for breach of representation.

On November 19, 2001, we filed a lawsuit against PNM in the Supreme Court of the State of New York. The lawsuit seeks substantial damages for PNM’s breach of the merger agreement providing for PNM’s purchase of our electric utility operations and for PNM’s breach of its duty of good faith and fair dealing. In addition, we filed a motion to dismiss or stay the declaratory judgment action previously filed by PNM seeking a declaratory judgment that PNM has no further obligations under the merger agreement.

PNM responded to our motion by seeking to dismiss or stay our action in favor of its own. On May 2, 2002, the Court granted PNM’s motion to dismiss our lawsuit, without prejudice to our assertion of all claims alleged therein as counterclaims in the earlier-filed PNM case, and correspondingly denied our motion to dismiss the earlier-filed PNM lawsuit. On May 10, 2002, PNM served us with an amended complaint in which it added to its prior claims requests for declarations that PNM did not breach the terms of the merger agreement and also alleged additional breaches of representations and warranties on our part.

We and our subsidiaries are involved in various other legal, environmental and regulatory proceedings. We believe that adequate provision has been made and accordingly believe that the ultimate disposition of such matters will not have a material adverse effect upon our overall financial position or results of operations. See also Notes 5 and 6 for discussion of FERC proceedings and KCC regulatory proceedings.

12. RELATED PARTY TRANSACTIONS

Below we describe significant transactions between us and Westar Industries and other subsidiaries and related parties. We have disclosed significant transactions even if these have been eliminated in the preparation of our consolidated results and financial position since our proposed financial plan, as discussed in Note 6, calls for a split-off of Westar Industries from us to occur in the future. We cannot predict whether the KCC will approve the plan and, if so, whether we will be successful in executing the plan.

Transactions with Westar Industries

On February 28, 2001, Westar Industries converted $350.0 million of the then outstanding balance of a payable due from us into approximately 14.4 million shares of our common stock, representing 16.9% of our outstanding common stock after conversion. During the first quarter of 2002, we paid the remaining payable balance owed to Westar Industries of approximately $68 million. The proceeds were used by Westar Industries to purchase our outstanding debt in the open market, which we have accounted for as debt extinguishments. At March 31, 2002, Westar Industries owned $109.8 million of our debt securities. Amounts outstanding and interest earned by Westar Industries have been eliminated in our consolidated financial statements. At March 31, 2002, Westar Industries and Protection One owned 15,494,755 shares, or 17.8%, of our outstanding common stock. These shares are reflected as treasury stock in our consolidated balance sheets and are not included in our earnings per share calculation.

Transactions Between Westar Industries and Subsidiaries

Protection One Credit Facility

Westar Industries is the lender under Protection One’s senior credit facility. On March 25, 2002, Westar Industries and Protection One entered into an amendment to the facility that increased the amount of the facility to $180 million. As of March 31, 2002, approximately $143.5 million was drawn under the facility. Amounts outstanding, accrued interest and facility fees have been eliminated in our consolidated financial statements. The facility currently expires on January 3, 2003.

Purchases of Securities

During the three months ended March 31, 2002, Westar Industries purchased $38.5 million face value of Protection One bonds on the open market. We recognized an extraordinary gain from the purchase of Protection One bonds of $4.5 million, net of tax of $2.4 million.

During the three months ended March 31, 2002, both Westar Industries and Protection One purchased $91.1 million face value of Westar Energy bonds on the open market. We recognized an extraordinary gain from the purchase of our bonds of $2.0 million, net of $1.3 million tax. We recognized an extraordinary loss related to the fair value of a call option associated with our 6.25% senior unsecured notes at the time the notes were retired of $2.5 million, net of $1.7 million tax benefit, for the three months ended March 31, 2002.

During April 2002, we recognized a gain of $4.1 million, net of $2.3 million tax, on the repurchase of Protection One and our bonds. In April 2002, we recognized an extraordinary loss related to the fair value of a call option associated with our 6.25% senior unsecured notes at the time the notes were retired of $0.9 million, net of $0.6 million tax benefit.

During the three months ended March 31, 2002, Protection One purchased approximately $1.2 million of our preferred stock in open market purchases. These purchases have been accounted for as retirements. Additionally, we recognized a gain on reacquired preferred stock of approximately $0.5 million, net of tax of $0.3 million, for the three months ended March 31, 2002 related to these retirements. From April 1, 2002 through April 30, 2002, Protection One acquired in open market purchases approximately $0.1 million of our preferred securities.

Services Agreements

We provide administrative services to Protection One pursuant to services agreements, including accounting, tax, audit, human resources, legal, facilities and technology services. Charges of approximately $1.5 million for the three months ended March 31, 2002 and $2.4 million for the same period of 2001 were incurred by Protection One. We had a net intercompany balance due from Protection One primarily for these services of $0.9 million at March 31, 2002.

Protection One has entered into an agreement pursuant to which it will pay to Westar Industries, beginning with the quarter ended March 31, 2002, a fee for financial advisory services payable quarterly, equal to 0.125% of its consolidated total assets at the end of each quarter. The agreement also provides access to aviation services at Protection One’s option. This agreement was approved by the independent members of Protection One’s board of directors. Protection One incurred approximately $1.3 million of expenses in the first quarter of 2002 for the financial advisory fee, which has been eliminated in our consolidated financial statements.

Transactions with Protection One

During the fourth quarter of 2001, KGE entered into an option agreement to sell an office building located in downtown Wichita, Kansas, to Protection One for approximately $0.5 million. The sales price was determined by management based on three independent appraisers’ findings.

Loans to Officers

During 2001, we extended loans to our officers for the purpose of purchasing shares of our common stock on the open market. The loans are unsecured and contain a variable interest rate that is equal to our short-term borrowing rate. Interest is payable quarterly. The loans mature and become due on December 4, 2004. The balance outstanding at March 31, 2002 was approximately $2.1 million and is classified as a reduction to shareholders’ equity in the accompanying consolidated balance sheet. During the first quarter of 2002, we recorded approximately $22,000 in interest income on these notes. The maximum amount of loans authorized is $7.9 million.

13. SEGMENTS OF BUSINESS

Our business is segmented based on differences in products and services, production processes and management responsibility.

Previously, we had identified five reportable segments: Fossil Generation, Nuclear Generation, Customer Operations, Monitored Services and Other. We now have three reportable segments: Electric Utility, Monitored Services and Other. Electric Utility consists of our integrated electric utility operations doing business as Westar Energy. Monitored Services, including the net effect of minority interests, is comprised of our security alarm monitoring business in North America and Europe. Other includes a 45% interest in ONEOK, investments in international power generation facilities and other investments in the aggregate not material to our business or results of operations.

The accounting policies of the segments are substantially the same as those described in our Annual Report on Form 10-K for the year ended December 31, 2001 in Note 2, “Summary of Significant Accounting Policies.” Segment performance is based on earnings (losses) before interest and taxes (EBIT). Prior year segment information has been reclassified, as necessary, to conform with the current year’s presentation.

Three Months Ended March 31, 2002:
	Electric Utility		Monitored Services			Other (a) (b)		Total

	(In Thousands)

Sales	$	412,281	$	89,708		$	252	$	502,241
EBIT		22,714		(244,113	)		29,235		(192,164	)
Interest expense									61,883
Losses before income taxes									(254,047	)

Three Months Ended March 31, 2001:
	Electric Utility (c)		Monitored Services			Other (a) (d)		Total

	(In Thousands)

Sales	$	446,018	$	114,370		$	353	$	560,741
EBIT		42,814		(27,481	)		13,142		28,475
Interest expense									66,701
Losses before income taxes									(38,226	)


(a)	Sales are from a wholly owned subsidiary of Westar Industries providing paging services, which was sold during the first quarter of 2002.
(b)	EBIT includes investment earnings of $32.1 million consisting of a one-time payment of approximately $14.2 million related to a partial recovery of an investment and approximately $13.8 million of ONEOK investment earnings.
(c)	EBIT does not include the unrealized gain on derivatives reported as a cumulative effect of a change in accounting principle. If the effect had been included, EBIT would have been $73.9 million.
(d)	EBIT includes investment earnings of $11.7 million.

14. SUBSEQUENT EVENT

On May 10, 2002, we completed offerings for $365 million of our first mortgage bonds and $400 million of our unsecured senior notes, both of which will be due on May 1, 2007. The first mortgage bonds bear interest at the annual rate of 7 7/8% and the unsecured senior notes bear interest at the annual rate of 9 3/4%. Interest on the first mortgage bonds and unsecured senior notes is payable semi-annually on May 1 and November 1 of each year, beginning on November 1, 2002. The net proceeds from these offerings were used to repay outstanding indebtedness of $547 million under our existing secured bank term loan, provide for the repayment of $100 million of our 7.25% first mortgage bonds due August 15, 2002 together with accrued interest, reduce the outstanding balance on our existing secured revolving credit facility and pay fees and expenses of the transactions.

15. RESTATEMENTS OF OUR CONSOLIDATED FINANCIAL STATEMENTS

Call Option Contract

States Treasury rate on August 12, 2003 and 5.44%. If the 10-year United States Treasury rate on August 12, 2003 is less than 5.44%, we may have a liability to the investment bank at that time. At September 30, 2002, our potential liability under this contract was $69.9 million. Based on the current 10-year forward treasury rate on November 12, 2002 of 4.28%, we would potentially be obligated to make a cash payment of approximately $51.0 million to settle the contract on August 12, 2003. The amount of our liability will increase or decrease approximately $5 million for every 10-basis point change in the 10-year forward treasury rate. We are evaluating whether alternatives are available to reduce or eliminate the amount of the cash payment necessary to settle the call option.

At the time of issuance of the notes in 1998, in accordance with GAAP, we were not required to account separately for the call option. However, subsequent to the issuance of our consolidated financial statements for the three months ended March 31, 2002, we determined that when we began retiring these notes as a part of our overall debt reduction strategy, the portion of the call option associated with the retired notes became a free-standing option, and should have been treated as a derivative instrument under SFAS No. 133. The fair value of the call option should have been recognized at the date the notes were retired and should have been reflected as an extraordinary loss. In addition, under SFAS No. 133, we are required to mark to market changes in the anticipated amount of the liability related to the portion of the $400 million in notes that have been retired so that our balance sheet reflects the current fair value of the free standing portion of the call option contract. As a result, we recognized an extraordinary loss related to the fair value of a call option associated with our 6.25% senior unsecured notes at the time the notes were retired of $2.5 million, net of $1.7 million tax benefit, for the three months ended March 31, 2002. Related to the call option, we recorded a non-cash mark-to-market gain of $0.9 million, net of $0.6 million tax, for the three months ended March 31, 2002. We cannot predict changes in the market value of this option and therefore cannot estimate amounts of future mark-to-market non-cash charges associated with the call option.

Additional Impairment Charge at Protection One

On January 1, 2002, we adopted new accounting standards SFAS Nos. 142 and 144. As a result, we recorded our share of the impairment charge for goodwill recorded by Protection One, which was reflected in our consolidated statement of income as a cumulative effect of a change in accounting principle, and the impairment charge for Protection One’s customer accounts, which was reflected in our consolidated statement of income as an operating expense. See Note 3 for further information on the adoption of these standards.

Subsequently, Protection One has identified errors in the application of these new accounting standards. These errors relate primarily to the incorrect exclusion of deferred tax assets resulting from the customer account impairment charge in the completion of the goodwill impairment amount resulting from the classification of certain property and equipment as customer accounts. The additional charges increase the previously reported impairment charges and are reflected in the restated results for the three months ended March 31, 2002. As a result, we recorded an additional non-cash charge of approximately $93 million, net of tax of $15 million, for the three months ended March 31, 2002, which reflects our share of the additional non-cash impairment charge recorded by Protection One.

Comparison of Restated Amounts to Previously Reported Amounts

As a result of the above restatements, the accompanying consolidated financial statements as of and for the three months ended March 31, 2002 have been restated from the amounts previously reported to correct the accounting for these transactions. A summary of the effects of these restatements is as follows:

	As of March 31, 2002

Changes to Balance Sheet	As Previously Reported			As Restated

	(In Thousands)
Property, plant and equipment, net	$	4,021,097		$	4,027,029
Customer accounts, net		485,230			473,719
Goodwill, net		305,415			188,388
Total other assets		2,058,433			1,929,894
Total assets		6,590,252			6,467,645
Deferred income taxes and investment tax credits		750,389			732,383
Minority interests		82,395			69,150
Other long-term liabilities		282,214			284,976
Total long-term liabilities		3,820,831			3,792,342
Retained earnings (accumulated deficit)		(67,092	)		(161,210	)
Total shareholders’ equity		1,188,451			1,094,333
Total liabilities and shareholders’ equity		6,590,252			6,467,645

	Three Months Ended March 31, 2002

Changes to Income Statements	As Previously Reported			As Restated

	(In Thousands, Except Per Share Amounts)
Depreciation and amortization	$	74,917			74,587
Loss on impairment of customer accounts		334,064			339,974
Total operating expenses		601,493			607,073
Income (loss) from operations		(312,675	)		(318,255	)
Minority interests		83,323			96,569
Other income (expense)		(4,599	)		(3,186	)
Total other income		111,432			126,091
Earnings (losses) before interest and taxes		(201,243	)		(192,164	)
Losses before income taxes		(263,126	)		(254,047	)
Income tax benefit		(125,899	)		(127,290	)
Net loss before extraordinary gain and accounting change		(137,227	)		(126,757	)
Extraordinary gain, net of tax		6,463			3,948
Cumulative effect of accounting change, net of tax		(521,644	)		(623,717	)
Net income (loss)		(652,408	)		(746,526	)
Earnings (losses) available for common stock		(652,192	)		(746,310	)
BASIC AND DILUTED EARNINGS PER SHARE:
Basic and diluted earnings (losses) available from continuing operations before extraordinary gain and accounting change	$	(1.92	)	$	(1.77	)
Extraordinary gain, net of tax		0.09			0.05
Accounting change, net of tax		(7.31	)		(8.74	)

Basic and diluted earnings (losses) available after extraordinary gain	$	(9.14	)	$	(10.46	)

Securities and Exchange Commission Inquiry

Protection One, Arthur Andersen LLP, our former independent auditor, and we were advised on November 1, 2002 by the Staff of the Securities and Exchange Commission that the Staff will be inquiring into the accounting practices of Westar Energy with respect to the restatement of our first and second quarter 2002 consolidated financial statements announced in November 2002 and the related announcement that our and Protection One’s 2000 and 2001 financial statements will be reaudited. We intend to cooperate with the Staff in connection with this inquiry.

WESTERN RESOURCES, INC.

ITEM 2.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

As discussed in Note 15 of the Notes to Consolidated Financial Statements, “Restatement of Our Consolidated Financial Statements,” included in Item 1, the accompanying consolidated financial statements for the three months ended March 31, 2002 have been restated. The following Management’s Discussion and Analysis of Financial Condition and Results of Operations reflect the restatements.

INTRODUCTION

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations updates the information provided in our Annual Report on Form 10-K for the year ended December 31, 2001, and should be read in conjunction with that report. In this section, we discuss the general financial condition, significant changes and operating results for us and our subsidiaries. We explain:

	•	What factors impact our business
	•	What our earnings and costs were for the three months ended March 31, 2002 and 2001
	•	Why these earnings and costs differ from period to period
	•	How our earnings and costs affect our overall financial condition
	•	Any other items that particularly affect our financial condition or earnings.

SUMMARY OF SIGNIFICANT ITEMS

Impairment Charge Pursuant to New Accounting Rules

Effective January 1, 2002, we adopted the new accounting standards Statement of Financial Accounting Standards (SFAS) No. 142, “Accounting for Goodwill and Other Intangible Assets,” and SFAS No. 144, “Accounting for the Impairment and Disposal of Long-Lived Assets.” SFAS No. 142 establishes new standards for accounting for goodwill. SFAS No. 142 continues to require the recognition of goodwill as an asset, but discontinues amortization of goodwill. In addition, annual impairment tests must be performed using a fair-value based approach as opposed to an undiscounted cash flow approach required under prior standards.

SFAS No. 144 establishes a new approach to determining whether our customer account asset is impaired. The approach no longer permits us to evaluate our customer account asset for impairment based on the net undiscounted cash flow stream obtained over the remaining life of the goodwill associated with the customer accounts being evaluated. Rather, the cash flow stream to be used under SFAS No. 144 is limited to the future estimated undiscounted cash flows from customer accounts. If the undiscounted cash flow stream from customer accounts is less than the combined book value of customer accounts and goodwill, an impairment charge is required.

		Impairment of Goodwill		Impairment of Customer Accounts		Total

		(In Thousands)

Protection One		$	615,948	$	339,974	$	955,922
Protection One Europe			80,104		—		80,104

	Total pre-tax impairment	$	696,052	$	339,974		1,036,026

Income tax benefit							(190,676	)
Minority interest ownership							(95,886	)

	Total charge, net of tax					$	749,464

The impairment charge for goodwill is reflected in our consolidated statement of income as a cumulative effect of a change in accounting principle. The impairment charge for customer accounts is reflected in our consolidated statement of income as an operating expense. These impairment charges reduce the recorded value of these assets to their estimated fair values at January 1, 2002. See Note 15 of Notes to Consolidated Financial Statements, “Impairment Charge Pursuant to New Accounting Rules,” for information concerning the restatements to report an additional impairment charge for our share of the impairment charge for goodwill and customer accounts recorded by Protection One.

		Three Months Ended March 31,

		2002			2001

		(In Thousands, Except Per Share Amounts)

	Reported earnings (losses) available for common stock	$	(746,310	)	$	4,168
	Add back: Goodwill amortization		—			14,418

	Adjusted earnings (losses) available for common stock	$	(746,310	)	$	18,586

Basic and diluted earnings per share:
	Reported earnings (losses) available for common stock	$	(10.46	)	$	0.06
	Add back: Goodwill amortization		—			0.20

	Adjusted earnings (losses) available for common stock	$	(10.46	)	$	0.26

Securities and Exchange Commission Inquiry

Change in Estimate of Customer Life

During the first quarter of 2002, Protection One, Inc. (Protection One) evaluated the estimated life and amortization rates for customer accounts, given the results of a lifing study performed by a third party appraisal firm in the first quarter of 2002. The lifing study showed a deterioration in the average remaining life of customer accounts. Protection One’s management determined it was appropriate, given the results of the lifing study, to adjust the rate of amortization on customer accounts for its North America and Multifamily customer pools. In the first quarter of 2002, Protection One changed its amortization rate for its North America pool to a 10-year 135% declining balance method from a 10-year 130% declining balance method. For the Multifamily pool, Protection One reduced its estimated customer life from 10 to 9 years and will continue to amortize on a straight-line basis. We account for these amortization changes prospectively as a change in estimate. These changes in estimates increased amortization expense for the three months ended March 31, 2002 on a pre-tax basis by approximately $0.3 million. The change in estimate had no impact on reported earnings per share.

KCC Rate Proceedings

On November 27, 2000, we and Kansas Gas and Electric Company (KGE) filed applications with the Kansas Corporation Commission (KCC) for an increase in retail rates. On July 25, 2001, the KCC ordered an annual reduction in our combined electric rates of $22.7 million, consisting of a $41.2 million reduction in KGE’s rates and an $18.5 million increase in our rates.

KCC Proceedings and Orders

The merger with Public Service Company of New Mexico (PNM) contemplated the completion of a rights offering for shares of Westar Industries, Inc. (Westar Industries), prior to closing. On May 8, 2001, the KCC opened an investigation of the proposed separation of our electric utility businesses from our non-utility businesses, including the rights offering, and other aspects of our unregulated businesses. The order opening the investigation indicated that the investigation would focus on whether the separation and other transactions involving our unregulated businesses are consistent with our obligation to provide efficient and sufficient electric service at just and reasonable rates to our electric utility customers. The KCC staff was directed to investigate, among other matters, the basis for and the effect of the Asset Allocation and Separation Agreement we entered into with Westar Industries in connection with the proposed separation and the intercompany payable owed by us to Westar Industries, the separation of Westar Industries, the effect of the business difficulties faced by our unregulated businesses and whether they should continue to be affiliated with our electric utility business, and our present and prospective capital structures. On May 22, 2001, the KCC issued an order nullifying the Asset Allocation and Separation Agreement, prohibiting Westar Industries and us from taking any action to complete the rights offering for common stock of Westar Industries, which was to be a first step in the separation, and scheduling a hearing to consider whether to make the order permanent.

into any agreement not related to normal utility operations that would directly or indirectly increase the share of debt in our capital structure applicable to our electric utility operations, which has the effect of prohibiting us from borrowing to make a loan or capital contribution to Westar Industries; and (3) directed us to present a financial plan consistent with parameters established by the KCC’s order to restore financial health, achieve a balanced capital structure and protect ratepayers from the risks of our non-utility businesses. In its order, the KCC also acknowledged that we are currently operating efficiently and at reasonable cost and stated that it was not disapproving the PNM transaction or a split-off of Westar Industries. We appealed the orders issued by the KCC to the District Court of Shawnee County, Kansas. On February 5, 2002, the District Court issued a decision finding that the KCC orders were not final orders and that the District Court lacked jurisdiction to consider the appeal. Accordingly, the matter was remanded to the KCC for review of the financial plan.

On February 11, 2002, the KCC issued an order primarily related to procedural matters for the review of the financial plan, as discussed below. In addition, the order required that we and the KCC staff make filings addressing whether the filing of applications by us and KGE at the Federal Energy Regulatory Commission (FERC), seeking renewal of existing borrowing authority, violated the July 20, 2001 KCC order directing that we not increase the share of debt in our capital structure applicable to our electric utility operations. The KCC staff subsequently filed comments asserting that the refinancing of existing indebtedness with new indebtedness secured by utility assets would in certain circumstances violate the July 20, 2001 KCC order. The KCC filed a motion to intervene in the proceeding at FERC asserting the same position.

The Financial Plan

The July 20, 2001 KCC order directed us to present a financial plan to the KCC. For details of the financial plan and a hearing regarding the financial plan, see Note 6 of the “Notes to Consolidated Financial Statements” included herein and “Item 1. Business — Significant Business Developments — The Financial Plan” in our Annual Report on Form 10-K for the year ended December 31, 2001.

Extraordinary Gain on Securities

periods that were classified as extraordinary that do not meet the APB Opinion No. 30 criteria will be required to be reclassified. We do not anticipate this pronouncement to have an impact on our earnings or financial condition.

Work Force Reductions

Ice Storm

Debt Financings

Potential Changes in ONEOK Ownership

Westar Industries is reviewing alternatives for changing its investment in ONEOK. Among other things, Westar Industries may offer to ONEOK the option to purchase all or a portion of its interest in ONEOK and, in the event ONEOK fails to purchase Westar Industries’ interest, pursue its right to seek a third-party buyer within a 16-month period thereafter. Westar Industries also may pursue any other means available to it under the shareholder agreement governing ownership of its investment in ONEOK for changing its investment in ONEOK. We are unable to predict whether any transaction will be pursued or any potential impact.

OPERATING RESULTS

The following discussion explains significant changes in operating results for the three months ended March 31, 2002 and 2001.

Western Resources Consolidated

Sales decreased $58.5 million, or 10%. Lower retail and wholesale demand due to warm weather, lower industrial demand due to current economic conditions and decreased power marketing sales due to lower prices contributed approximately $33.7 million to the decrease. A decrease in Monitored Services sales caused by the decline in its customer base, which was due in part to attrition and dispositions in 2001 of certain monitored services operations, contributed approximately $24.8 million to the decrease. See
“¾ Business Segments” below for additional information.

Cost of sales decreased $56.2 million, or 21%. The decrease in the cost of sales was primarily due to decreased power marketing expense. Decreased power marketing expense was partially offset by increases in the mark to market on derivatives, purchased power expense and fuel expense. Protection One’s efforts to reduce costs through consolidation of services and other cost cutting measures also contributed to the decline in cost of sales. Gross profit decreased $2.3 million, from $291.1 million in the first quarter of 2001 to $288.8 million in the same period of 2002, due to the above mentioned factors. Gross profit as a percentage of sales increased from 52% during the 2001 period to 58% during the 2002 period.

Basic losses per share were $10.46 for the first quarter of 2002, compared to basic earnings per share of $0.06 for the first quarter of 2001. This decrease is primarily attributable to the impairment charge recorded in the first quarter of 2002, the decline in gross profit discussed above and the first quarter 2002 charge related to a work force reduction.

Business Segments

Our business is segmented based on differences in products and services, production processes and management responsibility.

Previously, we had identified five reportable segments: Fossil Generation, Nuclear Generation, Customer Operations, Monitored Services and Other. We now have three reportable segments: Electric Utility, Monitored Services, and Other. Electric Utility consists of our integrated electric utility operations, including the generation and purchase of power, the transmission and distribution of power to our retail customers in Kansas and to wholesale customers, and our power marketing activities, which attempt to minimize commodity price risk associated with fuel purchases and purchased power requirements. Monitored Services, including the net effect of minority interests, is comprised of our security alarm monitoring business in North America and Europe. Other includes a 45% interest in ONEOK, investments in international power generation facilities and other investments in the aggregate not material to our business or results of operations.

The accounting policies of the segments are substantially the same as those described in our Annual Report on Form 10-K for the year ended December 31, 2001 in Note 2, “Summary of Significant Accounting Policies” in the “Notes to Consolidated Financial Statements.” Prior year segment information has been reclassified, as necessary, to conform with the current year’s presentation.

We manage our business segments’ performance based on earnings (losses) before interest and taxes (EBIT). EBIT does not represent cash flow from operations as defined by generally accepted accounting principles, should not be construed as an alternative to operating income and is indicative neither of operating performance nor cash flows available to fund our cash needs. Items excluded from EBIT are significant components in understanding and assessing our financial performance. Interest expense, income taxes, extraordinary gains, cumulative effects of accounting changes and preferred stock are items that are excluded from the calculation of EBIT. We believe presentation of EBIT enhances an understanding of financial condition, results of operations and cash flows because EBIT is used by us to satisfy our debt service obligations, capital expenditures and other operational needs, as well as to provide funds for growth. Our computation of EBIT may not be comparable to other similarly titled measures of other companies.

Electric Utility

Our electric sales for the three months ended March 31, 2002 and 2001 are as follows:

		Three Months Ended March 31,

		2002		2001		% Change

		(In Thousands)

Residential		$	88,614	$	90,919		(2.5	)
Commercial			81,194		82,610		(1.7	)
Industrial			56,211		59,056		(4.8	)
Other			25,008		13,019		92.1

	Total retail	$	251,027	$	245,604		2.2
Wholesale and Interchange			62,897		64,642		(2.7	)
Power Marketing			70,469		122,588		(42.5	)
System Marketing			27,888		13,184		111.5

	Total	$	412,281	$	446,018		(7.6	)

The following table reflects changes in electric sales volumes, as measured by megawatt hours (MWh), for the three months ended March 31, 2002 and 2001. No sales volumes are included for power marketing and system marketing sales because these sales are not based on electricity we generate.

		Three Months Ended March 31,

		2002		2001		% Change

		(Thousands of MWh)

Residential			1,314		1,330		(1.2	)
Commercial			1,453		1,478		(1.7	)
Industrial			1,277		1,355		(5.8	)
Other			27		27		—

	Total retail		4,071		4,190		(2.8	)
Wholesale and Interchange			2,530		2,018		25.4

	Total		6,601		6,208		6.3

Energy sales decreased $33.7 million, or 8%. Residential sales decreased due to weather conditions and rate reductions ordered by the KCC. In our service territory, the heating season of 2002 was warmer than the heating season of 2001, which caused customers to use less energy to heat their homes during the winter. Commercial sales decreased primarily due to our rate reductions. Industrial sales decreased primarily due to economic conditions affecting our large industrial customers. Wholesale and interchange sales changed primarily due to weather and market conditions. Power marketing sales decreased because of lower prices. Increases in other revenues and system marketing sales partially offset these decreases. The increase in other revenues is attributable to the new Southwest Power Pool (SPP) network tariff. The new tariff requires us to pay to the SPP all expenses associated with transporting our power from our generating stations. The SPP then pays us for distributing power to our retail customers and these payments are reflected in other revenues. Prior to the implementation of the new tariff, we had offsetting revenues and expenses, because an internal allocation was used. The increase in system marketing sales was primarily due to increased marketing efforts.

Cost of sales is comprised of fuel used for generation, mark to market on derivatives, purchased power and power marketing expense. Cost of sales decreased $45.0 million, or 20%, primarily due to a $56.6 million decrease in power marketing expense as a result of the decrease in power marketing sales. Partially offsetting the decrease were increases of approximately $6.2 million due to marking to market derivatives, approximately $3.4 million in fuel expense and approximately $2.0 million in purchased power expense. Gross profit increased $11.3 million, or 5%, due to the above mentioned factors. This is partly due to how we were required to record a gain on certain derivatives acquired in 2001 to mitigate the risk of changing prices on our natural gas fuel requirements. Prior to the adoption of SFAS No. 133 on January 1, 2001, gains and losses on these derivatives were deferred until settlement and reflected in gross profit at that time. However, upon adoption of SFAS No. 133, we were required to report a $31.0 million gain on these contracts as of that date as a cumulative effect of a change in accounting principle. This gain was reported on our consolidated statements of income for the three months ended March 31, 2001 on a net-of-tax basis below income tax expense in accordance with accounting standards. All gains and losses after January 1,

2001 on our derivatives that are not designated as hedges are reflected in gross profit. Had we included the gain in cost of sales in 2001, our $11.3 million increase in gross profit would have been a decrease in gross profit of $19.7 million because the decline in sales would have been significantly greater than the decline in cost of sales.

A portion of the increase in fuel and purchased power expenses was attributable to the refueling and maintenance outage at Wolf Creek as other more expensive sources of power were used to replace the loss of power from Wolf Creek. Wolf Creek has a scheduled refueling and maintenance outage approximately every 18 months. Wolf Creek was shut down for 36 days for its 12th scheduled refueling and maintenance outage, which began on March 23, 2002 and ended on April 27, 2002. Wolf Creek operated the entire year of 2001 without any refueling outages.

During the three months ended March 31, 2002, operating expenses increased $32.1 million primarily as a result of employee severance costs related to the work force reduction.

Due to the above factors, income from operations decreased $20.8 million, which was the primary reason EBIT declined $20.1 million, from $42.8 million for the three months ended March 31, 2001 to $22.7 million for the same period of 2002.

Monitored Services

Protection One and Protection One Europe comprise our monitored services business segment. The results discussed below reflect Monitored Services on a stand-alone basis. These results take into consideration Protection One’s minority interest of approximately 12% at March 31, 2002 and 15% at March 31, 2001. Details concerning EBIT attributable to our monitored services segment are as follows:

	Three Months Ended March 31,

	2002			2001

	(In Thousands)

Sales	$	89,708		$	114,370
Loss before interest and taxes		(244,113	)		(27,481	)

Sales decreased $24.7 million primarily due to a decline in the monitored services segment’s average customer base, which was due in part to attrition and dispositions in 2001 of certain monitored services operations. The monitored services segment experienced a net decline of 16,562 customers in the first quarter of 2002. Protection One’s customer acquisition strategies have not been able to generate accounts in a sufficient volume at an acceptable cost to replace accounts lost through attrition. See “— Other Information — Monitored Services — Attrition” below for discussion regarding attrition. Protection One expects this trend will continue until the efforts it is making to acquire new accounts and reduce attrition become more successful than they have been to date. Until it is able to reverse this trend, net losses of customer accounts will materially and adversely affect its business, financial condition and results of operations. Protection One is currently focusing on reducing attrition, the development of cost effective marketing programs and the generation of positive cash flow.

Cost of sales generally relate to the cost of providing monitoring service and include the costs of monitoring, billing, customer service and field operations. Cost of sales decreased $11.1 million primarily due to Protection One’s reduced customer base, efforts to reduce costs through consolidation of services and other cost cutting measures and due to dispositions in 2001 of certain monitored services operations. As a result of sales declining at a higher rate than cost of sales, gross profit decreased $13.5 million.

During the three months ended March 31, 2002, operating expenses increased $298.0 million primarily due to a $340.0 million loss on impairment of customer accounts, which was partially offset by decreases in operating and maintenance, depreciation and amortization, and selling, general and administrative expenses. The decrease in depreciation and amortization expense of $31.2 million is primarily due to decreases in goodwill and customer account amortization. With the adoption of SFAS No. 142 on January 1, 2002, goodwill is no longer amortized.

As a result of the decline in gross profit and the increases in operating and other expenses, loss before interest and taxes increased $216.6 million. Also as a result of the impairment, Monitored Services’ total assets decreased approximately $1.1 billion, from $1.9 billion at December 31, 2001 to $821.9 million at March 31, 2002.

Other

Other includes a 45% interest in ONEOK, investments in international power generation facilities and other investments in the aggregate not material to our business or results of operations. Details concerning EBIT attributable to this segment are as follows:

	Three Months Ended March 31,

	2002		2001

	(In Thousands)

Sales	$	252	$	353
EBIT		29,235		13,142

Sales shown above are from a wholly owned subsidiary of Westar Industries providing paging services, which was sold during the first quarter of 2002. The timing of the disposition is the primary reason sales declined approximately $0.1 million. EBIT increased $16.1 million primarily as a result of increased investment earnings, which increased $20.4 million, from $11.7 million in 2001 to $32.1 million in 2002, primarily as a result of a one-time payment of approximately $14.2 million related to a partial recovery of an investment.

WESTERN RESOURCES CONSOLIDATED

The following discussion addresses changes in other items affecting net income but not affecting EBIT for the three months ended March 31, 2002 compared to the same period of 2001.

Interest Expense

Interest expense represents the interest we paid on outstanding debt. Interest expense decreased $4.8 million due to lower interest rates and lower outstanding debt at Protection One.

Income Taxes

LIQUIDITY AND CAPITAL RESOURCES

We had $93.6 million in cash and cash equivalents at March 31, 2002. We consider cash equivalents to be highly liquid investments with a maturity of three months or less when purchased. We also had $19.6 million of restricted cash classified as a current asset at March 31, 2002. The current asset portion of our restricted cash consists primarily of cash held in escrow as required by certain letters of credit. In addition, we had $35.1 million of restricted cash classified as a long-term asset, which consists

primarily of $34.1 million of cash held in escrow as required by the terms of a pre-paid capacity and transmission agreement and $1.0 million of cash used to collateralize letters of credit.

At March 31, 2002, current maturities of long-term debt were approximately $661.5 million and short-term debt outstanding was $397.7 million. Current maturities of long-term debt increased primarily due to our term loan, which had a maturity date of March 17, 2003.

On June 28, 2000, we entered into a $600 million, multi-year term loan that replaced two revolving credit facilities that matured on June 30, 2000. The term loan is secured by our and KGE’s first mortgage bonds and has a maturity date of March 17, 2003. The term loan agreement contains requirements for maintaining certain consolidated leverage ratios, interest coverage ratios and consolidated debt to capital ratios. At December 31, 2001, we were in compliance with all of these requirements. In January 2002, we repaid $44 million of the term loan with the proceeds of our sale of investments in low income housing tax credit partnerships. The outstanding balance of the term loan after this prepayment was $547 million. In March 2002, we entered into an amendment to the term loan that adds to the calculation of consolidated earnings before interest, taxes, depreciation and amortization, the severance costs incurred in the fourth quarter of 2001 and the first quarter of 2002 related to our work force reductions and maintains the current maximum consolidated leverage ratio of 5.75 to 1.0 through the maturity date of the term loan in March 2003. The outstanding balance of the term loan was repaid with a portion of the proceeds of our offerings of notes and first mortgage bonds on May 10, 2002.

We also have an arrangement with certain banks to provide a revolving credit facility on a committed basis totaling $400 million. The facility is secured by KGE’s first mortgage bonds and matures on March 17, 2003. In conjunction with the May 10, 2002 financings, we amended our revolving credit facility to reduce the total commitment under the facility to $400 million from $500 million and to release our first mortgage bonds as collateral. Borrowings on this facility were $397.7 million as of March 31, 2002. We used proceeds of $97 million from the May 10, 2002 financings to reduce the outstanding balance of the revolving credit facility. The outstanding balance of our revolving credit facility was $282.5 million as of May 10, 2002. Under the terms of the agreement, we are required, among other restrictions, to maintain a total debt to total capitalization ratio of not greater than 65% at all times. We are in compliance with this covenant. At March 31, 2002, the capitalization ratio was 61.6%. Under the terms of the facility, the impairment charge recorded in the first quarter of 2002 does not affect compliance with this covenant.

In August 1998, we entered into a call option contract with an investment bank related to the issuance of $400 million of our 6.25% senior unsecured notes that have a final maturity of August 15, 2018 and are putable and callable on August 15, 2003. This call option contract is required to be settled by August 2003 through either a remarketing or refinancing of the senior notes or a cash payment. If settled through a remarketing, the liability will be amortized as a credit to interest expense over the term of the new debt. The investment bank will price the notes to yield a market premium adequate to allow the investment bank to retain proceeds equal to the fair value of the call option at that time. The ultimate value of the call option will be based on the difference between the 10-year United States Treasury rate on August 12, 2003 and 5.44%. If the 10-year United States Treasury rate on August 12, 2003 is less than 5.44%, we may have a liability to the investment bank at that time. At September 30, 2002, our potential liability under this contract was $69.9 million. Based on the current 10-year forward treasury rate on November 12, 2002 of 4.28%, we would potentially be obligated to make a cash payment of approximately $51.0 million to settle the contract on August 12, 2003. The amount of our liability will increase or decrease approximately $5 million for every 10-basis point change in the 10-year forward treasury rate. We are evaluating whether alternatives are available to reduce or eliminate the amount of the cash payment necessary to settle the call option.

Credit Ratings

Standard & Poor’s (S&P), Fitch Investors Service (Fitch) and Moody’s Investors Service (Moody’s) are independent credit-rating agencies that rate our debt securities. These ratings indicate the agencies’ assessment of our ability to pay interest and principal on these securities. On April 2, 2002, Moody’s downgraded its ratings on Protection One’s outstanding securities with the outlook remaining negative. On April 18, 2002, Fitch lowered our senior unsecured debt ratings and reaffirmed that all our securities remain on Rating Watch Evolving. On April 25, 2002, S&P confirmed our ratings with a negative outlook. On April 29, 2002, Moody’s confirmed our ratings with a negative outlook.

As of April 30, 2002, ratings with these agencies are as follows:

Western
Resources
Mortgage
Bond
Rating

Western
Resources
Unsecured
Debt

KGE
Mortgage
Bond
Rating

Protection One
Senior
Unsecured
Debt

Protection One
Senior
Subordinated
Unsecured Debt

S&P

BBB-

BB-

BB+

CCC+

Fitch

BB+

BB-

BB+

CCC+

Moody’s

Ba1

Ba2

Ba1

Caa1

Caa3

In general, declines in our credit ratings make debt financing more costly and more difficult to obtain on terms which are economically favorable to us.

Cash Flows from (used in) Operating Activities

Cash provided by operating activities decreased $41.5 million to $17.3 million for the three months ended March 31, 2002, from $58.8 million for the same period of 2001. This decrease is mostly attributable to the severance and storm restoration costs incurred in the first quarter.

Cash Flows from (used in) Investing Activities

We spent $32.0 million during the three months ended March 31, 2002 in comparison to $63.1 million during the same period of 2001 on net additions to utility property, plant and equipment. During the first quarter of 2001, we spent $10.6 million on construction of our share of the State Line generating facility and $14.6 million on construction of our Gordon Evans combustion turbines. These major projects were completed during 2001. Investment in customer accounts amounted to $8.5 million in the first quarter of 2002 and $8.9 million in the same period of 2001.

Proceeds from other investments in the first quarter of 2002 amounted to $28.3 million primarily attributable to a one-time payment of approximately $14.2 million related to a partial recovery of an investment and $7.3 million received on the disposition of our portfolio of affordable housing tax credit limited partnerships.

Cash Flows from (used in) Financing Activities

We used net cash flows in financing activities of $8.2 million during the three months ended March 31, 2002 compared to net cash flows from financing activities of $16.6 million in the same period of 2001. In 2002, an increase in short-term debt was the principal source of cash flows from financing activities. Cash from financing activities was used to fund our required investment in operations, the retirement of long-term debt, and the payment of dividends on our common stock. Also in 2002, we used cash to redeem a portion of our preferred stock.

Capital Structure

During the first quarter of 2002, we recorded an impairment of our goodwill and customer accounts as more fully described above in “— Summary of Significant Items — Impairment Charge Pursuant to New Accounting Rules,” which affected our capital structure. Our capital structure at March 31, 2002 and December 31, 2001 was as follows:

		March 31, 2002			December 31, 2001

Shareholders’ equity			30	%		36	%
Preferred stock			1			1
Western Resources obligated mandatorily redeemable preferred securities of subsidiary trust holding solely company subordinated debentures			6			4
Long-term debt, net			63			59

	Total		100	%		100	%

Debt and Equity Repurchase Plans

Westar Industries and Protection One may, from time to time, purchase Protection One’s debt and equity securities in the open market or through negotiated transactions. We, Westar Industries and Protection One may also purchase our debt and equity. The timing and terms of purchases and the amount of debt or equity actually purchased will be determined based on market conditions and other factors.

OTHER INFORMATION

Electric Utility

FERC Proceeding

Our wholly owned subsidiary, Westar Generating, Inc. (Westar Generating), owns our interest in the State Line generating facility. We purchase Westar Generating’s share of the power generated by State Line. FERC has jurisdiction over the establishment of the rate at which we buy power from Westar Generating. We have reached a settlement in principle with the FERC staff and the KCC, the only active parties in this proceeding. We expect to file a Stipulation and Agreement in the near future.

Employees

A new agreement has been negotiated with the International Brotherhood of Electrical Workers that will be in effect through June 30, 2003. The new contract provides for wage increases of 2.5% to all classifications of employees covered by the agreement effective July 1, 2002. The contract covers approximately 1,100 employees as of April 30, 2002.

Monitored Services

Attrition

Customer attrition has a direct impact on the results of our monitored security operations since it affects its revenues, amortization expense and cash flow. See “— Operating Results — Monitored Services” and our Annual Report on Form 10-K for the year ended December 31, 2001 for additional information regarding customer attrition.

Customer attrition for the three months ended March 31, 2002 and 2001 is summarized below.

		Customer Account Attrition

		March 31, 2002				March 31, 2001

		Annualized First Quarter		Trailing Twelve Month		Annualized First Quarter		Trailing Twelve Month

Protection One			11.4%		14.4%		13.9%		14.7%
Protection One Europe (a)			10.8%		8.6%		8.9%		9.3%


(a)	United Kingdom operations were disposed of in June 2001.

Related Party Transactions

Below we describe significant transactions between us and Westar Industries and other subsidiaries and related parties. We have disclosed significant transactions even if these have been eliminated in the preparation of our consolidated results and financial position since our proposed financial plan, as discussed in Note 6 in the “Notes to Consolidated Financial Statements,” calls for a split-off of Westar Industries from us to occur in the future. We cannot predict whether the KCC will approve the plan and, if so, whether we will be successful in executing the plan.

Transactions with Westar Industries

On February 28, 2001, Westar Industries converted $350.0 million of the then outstanding balance of a payable due from us into approximately 14.4 million shares of our common stock, representing 16.9% of our outstanding common stock after conversion. During the first quarter of 2002, we paid the remaining balance owed to Westar Industries of approximately $68 million. The proceeds were used by Westar Industries to purchase our outstanding debt in the open market, which we have accounted for as debt extinguishments. At March 31, 2002, Westar Industries owned $109.8 million of our debt securities. Amounts outstanding and interest earned by Westar Industries have been eliminated in our consolidated financial statements. At March 31, 2002, Westar Industries and Protection One owned 15,494,755 shares, or 17.8%, of our outstanding common stock. These shares are reflected as treasury stock in our consolidated balance sheets and are not included in our earnings per share calculation.

Transactions Between Westar Industries and Subsidiaries

Protection One Credit Facility

Purchases of Securities

During the three months ended March 31, 2002, both Westar Industries and Protection One purchased $91.1 million face value of Westar Energy bonds on the open market. We recognized an extraordinary gain from the purchase of our bonds of $2.0 million, net of $1.3 million tax. Additionally we recognized an extraordinary loss related to the fair value of a call option associated with our 6.25% senior unsecured notes at the time the notes were retired of $2.5 million, net of $1.7 million tax benefit, for the three months ended March 31, 2002.

During the three months ended March 31, 2002, Protection One purchased approximately $1.2 million of our preferred stock in open market purchases. These purchases have been accounted for as retirements. We recognized a gain on reacquired preferred stock of approximately $0.5 million, net of $0.3 million tax, for the three months ended March 31, 2002 related to these retirements. From April 1, 2002 through April 30, 2002, Protection One acquired in open market purchases approximately $0.1 million of our preferred securities.

Services Agreements

approved by the independent members of Protection One’s board of directors. Protection One incurred approximately $1.3 million of expenses in the first quarter of 2002 for the financial advisory fee, which has been eliminated in our consolidated financial statements.

Transactions with Protection One

Loans to Officers

Market Risk Disclosure

We are exposed to market risk, including market changes, changes in commodity prices, equity instrument investment prices and interest rates. Since December 31, 2001, we have not experienced any significant changes in our exposure to market risk except for the impact of changes in our interest rate exposure on variable rate debt and current maturities of fixed rate debt. For additional information on our market risk, see our Annual Report on Form 10-K for the year ended December 31, 2001.

During the first quarter of 2002, $547 million was reclassified from long-term debt to current maturities. If there were a 100 basis point change in each debt series’ benchmark rate used to set the rate for such series, the impact to net income at March 31, 2002 would have been approximately $6.7 million after tax on an annual basis. However, it is anticipated that this exposure will decrease for the second quarter as a result of replacing existing debt with the proceeds from sales of our notes and first mortgage bonds on May 10, 2002. See “— Summary of Significant Items — Debt Financings” above for additional information about the financing agreement.

In August 1998, we entered into a call option contract with an investment bank related to the issuance of $400 million of our 6.25% senior unsecured notes that have a final maturity of August 15, 2018 and are putable and callable on August 15, 2003. This call option contract is required to be settled by August 2003 through either a remarketing or refinancing of the senior notes or a cash payment. If settled through a remarketing, the liability will be amortized as a credit to interest expense over the term of the new debt. The investment bank will price the notes to yield a market premium adequate to allow the investment bank to retain proceeds equal to the fair value of the call option at that time. The ultimate value of the call option will be based on the difference between the 10-year United States Treasury rate on August 12, 2003 and 5.44%. If the 10-year United States Treasury rate on August 12, 2003 is less than 5.44%, we may have a liability to the investment bank at that time. At September 30, 2002, our potential liability under this contract was $69.9 million. Based on the current forward rate on November 12, 2002 of 4.28%, we would potentially be obligated to make a cash payment of approximately $51.0 million to settle the contract on August 12, 2003. The amount of our liability will increase or decrease approximately $5 million for every 10-basis point change in the 10-year forward treasury rate. We are evaluating whether alternatives are available to reduce or eliminate the amount of the cash payment necessary to settle the call option.

In addition, under SFAS No. 133, we are required to mark to market changes in the anticipated amount of the liability related to the portion of the $400 million in notes that have been retired so that our balance sheet reflects the current fair value of the free standing portion of the call option contract. Related to the call option, we recorded a non-cash mark-to-market gain of $0.9 million, net of $0.5 million tax, for the three months ended March 31, 2002. We cannot predict changes in the 10-year United Stated Treasury rates and the market value of this option. Therefore, we cannot estimate amounts of future mark-to-market non-cash charges associated with the call option or the impact on our earnings, which could be material.

Hedging Activity

The following table summarizes the effects our natural gas hedges and our interest rate swap had on our financial position and results of operations for the three months ended March 31, 2002:

				Natural Gas Hedges (a)			Interest Rate Swap		Total Cash Flow Hedges

				(Dollars in Thousands)
Fair value of derivative instruments:
	Current			$	(5,191	)	$	—	$	(5,191	)
	Long-term				(6,011	)		516		(5,495	)

			Total	$	(11,202	)	$	516	$	(10,686	)

Amounts in accumulated other comprehensive income				$	19,032		$	3,173	$	22,205
Hedge ineffectiveness					964			—		964
Estimated income tax expense (benefit)					(8,089	)		—		(8,089	)

			Net Comprehensive Gain	$	11,907		$	3,173	$	15,080

Anticipated reclassifications to earnings in future periods (b)				$	(5,191	)	$	—	$	(5,191	)
Duration of hedge designation as of March 31, 2002					28 months			19 months		—


(a)		Natural gas hedge assets and liabilities are classified in the balance sheet as energy trading contracts. Due to the volatility of gas commodity prices, it is probable that gas prices will increase and decrease over the remaining 28 months that these relationships are in place.
(b)		The actual amounts that will be reclassified to earnings could vary materially from this estimated amount due to changes in market conditions.

Fair Value of Energy Trading Contracts

The tables below show the difference between the market value and the notional values of energy trading contracts outstanding for the three months ended March 31, 2002, their sources and maturity periods:

	Fair Value of Contracts

	(In Thousands)

Net fair value of contracts outstanding at the beginning of the period	$	2,309
Contracts realized or otherwise settled during the period		8,154
Fair value of new contracts entered into during the period		12,087

Fair value of contracts outstanding at the end of the period	$	22,550

	Fair Value of Contracts at End of Period

Source of Fair Value	Total Fair Value		Maturity Less Than 1 Year			Maturity 1-3 Years		Maturity 4-5 Years		Maturity in Excess of 5 Years

	(In Thousands)

Prices actively quoted (futures)	$	1,685	$	(1,149	)	$	2,834	$	—	$	—
Prices provided by other external sources (swaps and forwards)		19,052		15,448			1,083		2,521		—
Prices based on models and other valuation models (options and other)		1,813		(835	)		2,648		—		—

Total fair value of contracts outstanding	$	22,550	$	13,464		$	6,565	$	2,521	$	—

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Information relating to market risk disclosure is set forth in “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations — Other Information — Market Risk Disclosure” included herein.

WESTERN RESOURCES, INC.

Part II. Other Information

ITEM 1. LEGAL PROCEEDINGS

We, Westar Industries, Protection One, its subsidiary Protection One Alarm Monitoring, Inc. (Protection One Alarm Monitoring) and certain present and former officers and directors of Protection One are defendants in a purported class action litigation pending in the United States District Court for the Central District of California, “Alec Garbini, et al. v. Protection One, Inc., et al.,” No. CV 99-3755 DT (RCx). Pursuant to an Order dated August 2, 1999, four pending purported class actions were consolidated into a single action. On February 27, 2001, plaintiffs filed a Third Consolidated Amended Class Action Complaint (Third Amended Complaint). Plaintiffs purported to bring the action on behalf of a class consisting of all purchasers of publicly traded securities of Protection One, including common stock and bonds, during the period of February 10, 1998 through February 2, 2001. The Third Amended Complaint asserted claims under Section 11 of the Securities Act of 1933 and Section 10(b) of the Securities Exchange Act of 1934 against Protection One, Protection One Alarm Monitoring, and certain present and former officers and directors of Protection One based on allegations that various statements concerning Protection One’s financial results and operations for 1997, 1998, 1999 and the first three quarters of 2000 were false and misleading and not in compliance with generally accepted accounting principles. Plaintiffs alleged, among other things, that former employees of Protection One have reported that Protection One lacked adequate internal accounting controls and that certain accounting information was unsupported or manipulated by management in order to avoid disclosure of accurate information. The Third Amended Complaint further asserted claims against us and Westar Industries as controlling persons under Sections 11 and 15 of the Securities Act of 1933 and Sections 10(b) and 20(a) of the Securities Exchange Act of 1934. A claim was also asserted under Section 11 of the Securities Act of 1933 against Protection One’s auditor, Arthur Andersen LLP. The Third Amended Complaint sought an unspecified amount of compensatory damages and an award of fees and expenses, including attorneys’ fees. On June 4, 2001, the District Court dismissed plaintiffs’ claims under Sections 10(b) and 20(a) of the Securities Exchange Act. The Court granted plaintiffs leave to replead such claims. The Court also dismissed all claims brought on behalf of bondholders with prejudice. The Court also dismissed plaintiffs’ claims against Arthur Andersen LLP and the plaintiffs have appealed that dismissal. On February 22, 2002, plaintiffs filed a Fourth Consolidated Amended Class Action Complaint. The new complaint realleges claims on behalf of purchasers of common stock under Sections 11 and 15 of the Securities Act of 1933 and Sections 10(b) and 20(a) of the Securities Exchange Act of 1934. The new complaint does not assert any claims against Protection One Alarm Monitoring. On April 5, 2002, we, Protection One and the other defendants filed a motion to dismiss the Fourth Consolidated Amended Class Action Complaint. The motion is scheduled to be heard by the Court on June 10, 2002. Protection One and we cannot predict the impact of this litigation, which could be material.

On October 12, 2001, PNM filed a lawsuit against us in the Supreme Court of the State of New York. The lawsuit seeks, among other things, declaratory judgment that PNM is not obligated to proceed with the proposed merger based in part upon the KCC orders discussed below and other KCC orders reducing rates for our electric utility business. PNM believes the orders constitute a material adverse effect and make the condition that the split-off of Westar Industries occur prior to closing incapable of satisfaction. PNM also seeks unspecified monetary damages for breach of representation.

We and our subsidiaries are involved in various other legal, environmental and regulatory proceedings. We believe that adequate provision has been made and accordingly believe that the ultimate disposition of such matters will not have a material adverse effect upon our overall financial position or results of operations. See also Notes 5 and 6 of the “Notes to Consolidated Financial Statements,” included herein by reference, for discussion of FERC proceedings and KCC regulatory proceedings.

ITEM 2. CHANGES IN SECURITIES AND USE OF PROCEEDS

None

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

None

ITEM 5. OTHER INFORMATION

None

ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K

(a)	Exhibits:

	4.1*	-	Thirty-Fifth Supplemental Indenture dated May 10, 2002 between Western Resources, Inc. and BNY Midwest Trust Company, as Trustee.

	4.2*	-	Securities Resolution No. 2 dated as of May 10, 2002 under Indenture dated as of August 1, 1998 between Western Resources, Inc. and Deutsche Bank Trust Company Americas.

	99.1	-	Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

	*Previously filed.

(b)	Reports on Form 8-K filed during the three months ended March 31, 2002:

	Form 8-K filed January 9, 2002			-	Announcing that PNM notified us by letter that PNM’s board of directors took action to terminate the Agreement and Plan of Restructuring and Merger dated November 8, 2000 among PNM, us and certain other parties. By letter dated January 9, 2002 we objected to PNM’s action and stated our position that PNM has no basis to terminate the Agreement.

	Form 8-K filed February 27, 2002			-	Announcing financial results for fiscal year ended December 31, 2001, and the amount of a charge to be recorded in the first quarter of 2002 as a result of the adoption of new accounting standards related to accounting for goodwill and intangible assets.

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		WESTERN RESOURCES, INC.


Date:	November 13, 2002	By:	/s/ PAUL R. GEIST

			Paul R. Geist, Senior Vice President, Chief Financial Officer and Treasurer

CERTIFICATION PURSUANT TO

RULE 13a-14 UNDER THE

SECURITIES EXCHANGE ACT OF 1934

Each of the undersigned, as a member of a committee appointed by the Board of Directors of Westar Energy, Inc. performing similar or equivalent functions to those performed by a principal executive officer or chief executive officer of the company, certify that:

I have reviewed this amended quarterly report for the period ended March 31, 2002 on Form 10-Q/A of Westar Energy, Inc.;

Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this quarterly report;

Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this quarterly report;


Date:	November 13, 2002	By:	/S/ DOUGLAS T. LAKE

			Douglas T. Lake Executive Vice President and Chief Strategic Officer As a Member of the Committee
		By:	/S/ PAUL R. GEIST
			Paul R. Geist Senior Vice President, Chief Financial Officer and Treasurer As a Member of the Committee
		By:	/S/ LARRY D. IRICK
			Larry D. Irick Vice President, Corporate Secretary As a Member of the Committee
		By:	/S/ RICHARD A. DIXON
			Richard A. Dixon Senior Vice President, Customer Operations As a Member of the Committee
		By:	/S/ DOUGLAS R. STERBENZ
			Douglas R. Sterbenz Senior Vice President, Generation and Marketing As a Member of the Committee
		By:	/S/ KELLY R. HARRISON
			Kelly B. Harrison Vice President, Regulatory As a Member of the Committee
			/S/ BRUCE A. AKIN
			Bruce A. Akin Vice President, Business Services As a Member of the Committee

CERTIFICATION PURSUANT TO
RULE 13a-14 UNDER THE
SECURITIES EXCHANGE ACT OF 1934
FOR A PERIOD ENDED PRIOR TO AUGUST 29, 2002

I, Paul R. Geist, certify that:

	1.	I have reviewed this amended quarterly report for the period ended March 31, 2002 on Form 10-Q/A of Westar Energy, Inc.;

	2.	Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this quarterly report; and

	3.	Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this quarterly report.

Date:	November 13, 2002	By:	/s/ PAUL R. GEIST

			Paul R. Geist, Senior Vice President, Chief Financial Officer and Treasurer

Evergy Kansas Central 10-Q/A2002 Q1 Quarterly report (amended)